PrimeEnergy Corporation — FY2014 Form 10-K
Reporting period: Fiscal year ended December 31, 2014; this is an annual filing, not a standalone fourth-quarter report. The filing identifies the registrant as PrimeEnergy Corporation, although the request metadata says PrimeEnergy Resources Corp. The company is an independent U.S. oil and gas producer that also provides well-servicing and field-construction services.
Financial performance and liquidity
- Revenue: $144.6 million, up 15.6% from $125.1 million in 2013. Oil and gas sales were $91.0 million, down 1.9%; field-service income was $26.3 million, up 5.4%.
- Profit: Operating income was $47.0 million versus $24.5 million. Net income attributable to PrimeEnergy was $27.0 million ($11.45 basic per share), compared with $12.3 million ($5.04) in 2013. Diluted EPS was $8.68 versus $3.86.
- Drivers and earnings quality: Results included $17.6 million of unrealized derivative gains, $6.1 million gain on asset sales/exchanges and a $1.8 million gain on asset-retirement settlements. Oil and gas sales declined despite higher gas prices and oil production because realized oil prices fell. The filing attributes much of the earnings increase to derivatives, field-service income and asset-sale gains.
- Cash flow and investment: Operating cash flow was $56.2 million, up from $35.7 million. Capital expenditures were $38.8 million; proceeds from property and equipment sales were $6.8 million. Cash and cash equivalents ended at $9.2 million, with a further $3.9 million classified as restricted cash.
- Debt and liquidity: Total borrowings were approximately $101.4 million at year-end, including $88.9 million under the revolving facility and $12.0 million of equipment loans. The revolver had a $130 million borrowing base and $41.1 million available at December 31. Management reported covenant compliance and expected compliance for the following 12 months. Substantially all oil and gas properties secure the credit facility.
- Balance sheet: Total assets were $264.9 million, total liabilities $186.6 million and total equity $78.3 million. Current assets were $43.8 million and current liabilities $38.7 million. Asset-retirement obligations totaled $12.5 million.
Operations and changes versus 2013
- Oil production increased 4% to 759,000 barrels; natural gas production declined 3% to 4,741 MMcf. Average realized prices excluding derivatives were $86.73 per barrel of oil, down 7%, and $5.32 per Mcf of gas, up 7%.
- Proved reserves increased to 37.2 million Boe from 30.3 million Boe. Proved undeveloped reserves rose to 23.4 million Boe, or about 63% of total reserves; West Texas accounted for about 84% of total proved reserves.
- Reserve standardized measure increased to $343.3 million from $238.2 million. The filing cautions that this SEC-defined estimate is not fair market value and uses prescribed prices, costs and a 10% discount rate.
- Development spending was $36.4 million. The company participated in 25 gross (11.8 net) wells in 2014, all reported as producing. It shifted its strategy toward horizontal drilling and away from some vertical locations.
- Revolving-facility debt declined from $112.5 million at year-end 2013 to $88.9 million at year-end 2014. Total borrowings declined from approximately $122 million to $101 million.
Outlook, risks and unusual items
- Management planned up to four initial horizontal wells in Upton County, Texas, at an estimated company cost of about $10 million. A broader Apache-partnered program was described as potentially involving about 60 wells over 18–24 months, with total program costs of approximately $470 million and an estimated company share of about $120 million. Timing and well count may change with commodity conditions.
- Management identified cash from operations and the credit facility as principal liquidity sources. It described most capital spending as discretionary and said spending depends on commodity conditions, prospects and available opportunities. No formal earnings or production guidance is provided in the supplied filing text.
- Commodity-price exposure is significant. The filing reports early-2015 average prices of $48.98 per barrel for oil and $2.92 per MMBtu for gas, materially below 2014 averages. Lower prices can reduce cash flow, borrowing capacity and economic drilling opportunities.
- Commodity derivatives are not hedge-accounted; fair-value changes flow through earnings and can create substantial reported volatility. Derivative fair values use Level 3 inputs, including basis differentials and volatility assumptions. Counterparty performance and production volumes also pose risks.
- Other material risks include reserve-estimation uncertainty, drilling and operating hazards, dependence on third-party operators and transport/processing access, environmental and hydraulic-fracturing regulation, customer concentration, and potential borrowing-base reductions. Plains All American and Sunoco represented 46% and 26% of oil sales; Atlas Pipeline Mid-Continent and Unimark represented 37% and 13% of gas sales. The company reported no long-term purchase agreements with these buyers.
- The company reported no material legal proceedings and no material subsequent events through issuance of the financial statements. Management concluded disclosure controls and internal control over financial reporting were effective at December 31, 2014; the auditor did not provide an internal-control attestation.
Key facts for investors to verify
- Confirm the registrant identity and reconcile the metadata name with the filing’s “PrimeEnergy Corporation” name.
- Assess how much 2014 earnings depended on unrealized derivative gains, asset-sale gains and the asset-retirement settlement gain, versus recurring operating performance.
- Verify the 2015 borrowing base, covenant headroom and funding capacity for the planned horizontal program, especially under lower commodity prices.
- Review the assumptions and development schedule behind the 23.4 million Boe of proved undeveloped reserves and the increase in standardized-measure value.
- Evaluate the company’s exposure to concentrated oil and gas purchasers, derivative counterparties, and potential reductions in production or prices.